Receiver array using tubing conveyed packer elements

ABSTRACT

A clamped receiver array using tubing conveyed packer elements is disclosed and described. The receiver array can be used for borehole seismology as well as marine bottom surface seismology. The receiver array has a plurality of receivers connected together by a signal cable. The apparatus is further provided with a fluid conduit running essentially parallel to the signal cable. The fluid conduit has a plurality of receiver deployment sections which are located proximate to respective receivers. The receiver deployment sections are responsive to an increase in pressure within the fluid conduit, causing the receiver deployment sections to operate to press the receiver against the inside of a wellbore or to a marine bottom surface. In one example the receiver deployment section uses pistons disposed in openings in the fluid conduit to push the receivers away from the conduit as pressure in the conduit is increased.

REFERENCE TO RELATED APPLICATIONS

This application is a continuation-in-part of U.S. patent applicationSer. No. 09/394,465, filed Sep. 11, 1999, now U.S. Pat. No. 6,206,133,issued Mar. 27, 2001, which is in turn a continuation-in-part of U.S.patent application Ser. No. 09/038,856, filed Mar. 11, 1998, now U.S.Pat. No. 5,962,819.

TECHNICAL FIELD

This invention relates to the field of geophysical seismic receivers,and more particularly to downhole and marine bottom geophysical receiverarrays.

BACKGROUND OF THE INVENTION

An emerging area in the field of seismology is the area of boreholeseismology. In traditional seismology, both a source and sensors havebeen either located at the surface, or the receiver have been locateddownhole while the source has been located on the surface. In boreholeseismology, the source is placed in a borehole while the receivers maybe either on the surface, or preferably in a borehole as well. Thislater mode is known as “cross-well seismology.” Borehole seismology isparticularly useful in determining the condition of an existingreservoir, following the history of a producing reservoir, and exploringpotential new reservoirs. Borehole seismology also makes it possible toroutinely record shear waves which allows for mapping lithology of oiland gas reservoirs.

A limiting factor in borehole seismology has been the lack of receiverarrays for boreholes which provide the dense spatial sampling requiredto make use of the high seismic frequencies made possible by theconsolidated geologic formation. Shear (S) waves, for example, have onlyhalf the wave length of compressional (P) waves, further increasing theneed for dense spatial sampling. The recording of compressional waves aswell as polarized shear waves makes it possible to map the mechanicalproperties of oil and gas reservoirs, as well as map and distinguishbetween different fluids and the effect of lithology. This informationmay also be used to map differential field stresses, which is theprimary source for differential permeability in a reservoir. Further,high signal to noise ratios, as well as a dense spatial sampling, willallow for direct use of attenuation of compressional and shear waves forcharacterization of oil and gas reservoirs. This combination of seismicmeasurements will allow much more information to be extracted about thetrue nature of oil and gas reservoirs.

In order to record and collect this required volume of measurements fromborehole seismology, what is needed is a seismic receiver array whichmay be deployed within a borehole and which has the capability ofdetecting both compressional and shear waves, as well as transmittingthis information from the borehole to the surface where it may befurther collected and/or processed. However, the borehole environmentmakes it difficult to record useful seismic data for boreholeseismology. Merely lowering an array of hydrophones into a borehole istypically insufficient to record the data necessary for useful boreholeseismology. Hydrophones are susceptible to recording energy from tubewave noise, which may obscure useful seismic signals. Further, in a gasfilled well hydrophones are useless, as the gaseous fluid in theborehole do not conduct the energy from the borehole to the hydrophone.

Therefore, what is needed is a receiver which can be used for boreholeseismology. More particularly, what is needed is a receiver array whichcan be deployed within a borehole and which will record shear andcompressional waves useful in characterizing the reservoir, as well astransmit the received data to a surface location where it may beutilized.

BRIEF DESCRIPTION OF THE DRAWINGS

Preferred embodiments of the invention are described below withreference to the following accompanying drawings.

FIG. 1 is an environmental view showing one embodiment of a receiverarray described herein deployed within a borehole in a reservoir.

FIG. 2 is a side elevation view showing one embodiment of a portion of areceiver array described herein deployed within a borehole.

FIG. 3 is a sectional view of the receiver array shown in FIG. 2.

FIG. 4 is a side elevation detail of an expansible section connectorwhich can be used in the receiver array described herein.

FIG. 5 is a sectional detail of an expansible section connector whichcan be used in the receiver array described herein.

FIG. 6 is a side elevation view showing the receiver array of FIG. 2 ina activated position wherein the receiver is coupled to the boreholewall.

FIG. 7 is side elevation view of an alternate embodiment of the receiverarray shown in FIG. 2.

FIG. 8 is a top sectional view of the receiver array shown in FIG. 7.

FIG. 9 is a sectional view of a positioning device which may be used ina receiver array as described herein.

FIG. 10 is a plan view of a positioning ring used to maintain theposition of the receiver relative to the expansive element.

FIG. 11 is side elevation view of an alternate embodiment of thereceiver array shown in FIG. 7.

FIG. 12 is a top sectional view of the receiver array shown in FIG.

FIG. 13 is a top sectional view of an alternate embodiment of thereceiver array shown in FIG. 12.

FIG. 14 is a side elevation sectional view of an alternate embodiment ofthe receiver array shown in FIG. 7.

FIG. 15 is a side elevation sectional view of an alternate embodiment ofthe receiver array shown in FIG. 7.

FIG. 16 is a side elevation sectional view of an alternate embodiment ofthe receiver array shown in FIG. 7.

FIG. 17 is a side elevation view of an apparatus in accordance with thepresent invention deployed on a bottom surface in a marine environment.

FIG. 18 is a side elevation sectional view of the apparatus depicted inFIG. 17.

SUMMARY OF THE INVENTION

An apparatus for detecting geophysical energy is disclosed. Theapparatus has a receiver configured to receive geophysical energy, theenergy being characterized by certain characteristics associated withgeophysical energy. The receiver converts the geophysical energy into asignal which is representative of at least one characteristic of thegeophysical energy. The device further includes a signal transportdevice configured to accept the signal from the receiver and relay thesignal to a remote location. The apparatus further includes a fluidconduit configured to contain a pressurized fluid. The fluid conduit hasa receiver deployment section which is located proximate to thereceiver. The receiver deployment section is responsive to an increasein pressure within the fluid conduit, causing the receiver deploymentsection to operate to press the receiver against the inside of awellbore to achieve beneficial coupling between the receiver and thewellbore. The receiver deployment section can be configured in a numberof different ways.

In one embodiment the receiver deployment section comprises anexpansible segment in the fluid conduit which expands as pressure withinthe fluid conduit is increased. The expansible segment then pressesagainst the receiver, pushing the receiver towards the wall of thewellbore. In another embodiment the receiver deployment sectioncomprises a mechanical actuator which presses the receiver towards thewall of the wellbore.

In one example of a mechanical actuator the receiver deployment sectioncomprises a spring disposed between the conduit and the receiver andconfigured to bias the receiver away from the conduit to the secondposition. A releasable latch temporarily secures the receiver in a firstposition proximate to the fluid conduit. A latch release device isconfigured to release the latch in response to pressure within theconduit to allow the receiver to move to a second position more distalfrom the fluid conduit than the first position. The latch can bepivotally mounted to a support member and can be configured to releasethe receiver when the latch is pivoted. The latch release device cancomprise a piston movably disposed through an opening in the conduit.The piston has a first end configured to push the latch and cause it topivot when the piston is moved in the opening in the conduit. The pistonmoves within the opening in the conduit as a result of a differentialpressure between the interior and the exterior of the conduit.

In another example of a mechanical actuator the receiver deploymentsection comprises a first piston movably disposed through a firstopening in the conduit. The first piston has a first piston first endconfigured to contact the receiver and to move the receiver from thefirst position to the second position when the first piston is moved inthe first opening in the conduit. The first piston moves within thefirst opening in the conduit as a result of a differential pressurebetween the interior and the exterior of the conduit. The actuator canfurther include a second piston configured similarly to the first pistonto provide additional deployment force on the receiver.

In yet another example of a mechanical actuator the receiver deploymentsection comprises a receiver housing attached to the fluid conduit andconfigured to receive at least part of the receiver when the receiver isin the first position. A first connector pad is connected to thereceiver. The device further includes a first clamping arm defined by afirst end and second end, the clamping arm first end being pivotallyattached to the receiver housing. The clamping arm second end ispivotally attached to the first connector pad. A first piston is movablydisposed through a first opening in the conduit. The first piston has afirst end configured to contact the first clamping arm and to move thefirst clamping arm when the first piston is moved in the first openingin the conduit. The first piston moves within the first opening in theconduit as a result of a differential pressure between the interior andthe exterior of the conduit. The device can further include a secondclamping arm and a second piston configured similarly to the firstclamping arm and the first piston to provide additional force on thereceive when deploying the receiver from the apparatus.

Although in the following discussion I may refer to the expansiblesegment as being the apparatus which moves the receiver towards the wallof the wellbore, it is understood that the expansible segment can besubstituted for any other the other receiver deployment sectionsdisclosed herein.

The system described herein provides for 1) a small receiver pod; 2) lowweight of the receiver pod; 3) high clamping force provided by thereceiver deployment section; and 4) high clamp force to weight ratio.

DETAILED DESCRIPTION OF PREFERRED EMBODIMENTS OF THE INVENTION

An apparatus for detecting geophysical energy is described herein. Theapparatus comprises a receiver, a signal transport device, and a fluidconduit having a receiver deployment section located proximate to thereceiver. An increase of fluid pressure within the fluid conduit causesthe receiver deployment section to actuate, pressing the receiver to asurface, such as the wall of a wellbore or an ocean bottom surface,allowing improved signal reception by the receiver.

Preferably, the apparatus comprises a plurality of receivers and acommon fluid conduit, the common fluid conduit having a plurality ofreceiver deployment sections located proximate to each receiver, suchthat an increase of pressure within the fluid conduit will causeessentially simultaneous actuation of all of the receiver deploymentsections. Thus, when the receiver array is for example located within aborehole, the receiver deployment sections may all be actuated at anessentially common instant to cause the receivers to be clamped withinthe wellbore at essentially the same time. The fluid conduit 40 can befabricated from tubing such as production tubing. The fluid conduit canalso comprise coiled tubing, which can be deployed from a spool as shownin FIG. 1. The receiver deployment sections can be considered as packerelements when the array is disposed in a wellbore. Thusly, the apparatuscan be described as a clamped receiver array using production tubingconveyed packer elements.

In the receiver array embodiment, a large number of receivers can becoupled together over a long distance, for example 1,000 meters (m) ormore. Thus, when the receiver array is deployed within a borehole, asupport mechanism is preferably provided to support the weight of thereceiver array while it is in an unclamped position. One embodiment ofthe invention described herein incorporates tensile strength members toeliminate the need for a separate support mechanism to support theweight of the apparatus within a wellbore. When the receiver array isdeployed within a wellbore and the receiver deployment section comprisesan expansible section, local receivers, and the outer surface of anexpansible section proximate to the receiver, will normally be exposedto localized pressures within the wellbore. One method of causing theexpansible section to expand and move the receiver into contact with thewellbore wall is to increase the pressure within the fluid conduit to apressure greater than that within the wellbore at that point. Thus, adifferential pressure is generated to actuate the apparatus to causecoupling of the receiver within the wellbore. A similar result isachieved for other types of receiver deployment sections disclosedherein. In one embodiment, the apparatus includes a flow or pressurefused valve located at the end of the fluid conduit which is disposedwithin the wellbore to allow fast acting response of the receiverdeployment sections in response to a pressure increase within the fluidconduit over the local pressure within the wellbore.

FIG. 1 shows an exemplary clamped receiver array 100 in an environmentalview wherein the receiver array is deployed within a wellbore 5 in anearth formation 2. In the embodiment shown in FIG. 1, the apparatus 100may properly be described as a downhole clamped receiver array. Thereceiver array 100 has a plurality of receiver sections 10 havingreceivers 20 connected by a common signal cable 30. Essentially parallelto the signal cable 30 is the fluid conduit 40. The fluid conduit 40 hasexpansible sections 50 located adjacent to receivers 20. The expansiblesections act as the receiver deployment sections in this embodiment. Inthis embodiment fluid conduit 40 comprises coil tubing such that theapparatus can be wound onto a spool 8 which can be supported by avehicle 6, allowing easy transportation and deployment of the apparatuswithin a wellbore. Although in the preferred embodiment a plurality ofreceivers and expandable sections are employed in the apparatus, it isunderstood that the apparatus can be constructed and deployed using onlya single receiver and a single expansible section. For exemplarypurposes only, a signal cable 30 can be provided with between 20 and2000 receivers spaced between about 0.3 m and 60 m apart.

Turning now to FIG. 2, a detail of the apparatus 10 having a singlereceiver 20, associated fluid conduit 40, and expansible section 50 isshown deployed within a wellbore having a casing 5. The apparatuspreferably further includes positioning devices 70 which are useful inpositioning and protecting the receiver 20 and the fluid conduit 40within the casing 5. Centralizing the receiver 20 and the fluid conduit40 within the casing 5 is beneficial to reduce unwanted contact betweenthese components while the apparatus 10 is being inserted into thecasing. Such unwanted contact can cause damage to the apparatus, and istherefore undesirable. The positioning device 70 can also be utilized toconnect the signal cable 30 to the fluid conduit 40 to reduce relativemovement there between. In one embodiment of the invention wherein onlya single receiver is employed, the signal cable section 114 and thefluid conduit section 112 are terminated shortly below positioningdevice 116. In a first variation on the single receiver embodiment, thesignal cable section 114 and the fluid conduit section 112 are absent orterminated just below the receiver second end 26 and the expansiblesection second end 118, respectively.

In yet an alternate embodiment of the apparatus, several receivers 20can be connected to the signal cable 30 between expansible sections 50.That is, receiver arrays wherein certain receivers are not provided withdedicated expansible sections can be employed.

Turning now to FIG. 3, a cross-sectional view of the apparatus 10 ofFIG. 2 is shown. The major components of the apparatus 10 shown in FIG.3 are the receiver 20, the signal cable 30, the fluid conduit 40, andthe expansible section 50. The expansible section 50 is connected tofluid conduit sections 42 and 112 by expansible section connector 60.The apparatus 100 of FIG. 1 can further include an orienting device 170,which can comprise a gyroscopic orienting apparatus. Orienting device154 is useful for determining the compass direction of the apparatus 100in the borehole 5. Each component will now be described in furtherdetail.

The Receiver

The receiver 20 is a receiver configured to receive geophysical energyand record certain characteristics associated with the geophysicalenergy. The geophysical energy can be characterized by suchcharacteristics as frequency, amplitude, polarization, and the directionof propagation of the energy wave associated with the geophysicalenergy. Preferably, the receiver has sensors 22 which can comprise3-component or 3-dimensional geophones. Such geophones recordgeophysical seismic energy moving in a vertical direction, as well as ina first and a second horizontal direction. One example of sensors usedin a receiver in the present invention are 30 Hz, 3-component geophoneshaving a frequency range of 10 Hz to 1,000 Hz and being digitized with asample rate of between and including 2 ms and ¼ ms. In addition to the3-component sensor described, 1, 2, or 4-component sensors can also beemployed.

In one example, the receiver 20 includes a polyurethane pod or casing142 having a diameter of 7 cm and a length of approximately 30 to 36 cm.The geophones 22 are preferably epoxied within the casing 142. Thegeophones 22 are preferably further potted in a semi-rigidrubber/plastic compound to absorb thermal and pressure strain on thegeophone holder 144. Holder 144 is preferably fabricated from aluminum.The geophone holder 144 is preferably potted with R828 Epon epoxy,available from Shell Chemical Company.

The receiver 20 is held in relative position to the expansible section50 by positioning device 70, as described below. The receiver 20 of FIG.3 preferably further includes locator rings 156 which are configured toprevent the receiver 20 from moving laterally with respect to the fluidconduit 40. Locator ring 156, shown in detail in FIG. 10, includes anopening 160 to receive receiver 20, and a concave portion 158 to receivethe expansible section 50.

Signal Cable

In response to geophysical energy received by sensor 22, the receiver 20produces a signal which can then be communicated to a remote location,such as to a surface location where the signal can be recorded orfurther processed. A device for communicating the signal can include thesignal cable 30 of FIG. 3. Other signal transmitting devices can beemployed, such as radio transmission. The signals can be transmitted torecorder 172 of FIG. 1.

Signal cable 30 further includes a signal conductor 36. Examples ofsignal conductors 36 are metal wires or optical fibers. For example, ina receiver array having 80 3-component receivers resulting in 240channels for data transmission, a 256 twisted pair cable was used forthe signal conductors. The twisted pairs were of #28 wire with thinbraided shield around the bundle. The wires were coated with a dualcopolymer/polypropolene insulation rated at 176° C. (350° F.). The cablewas jacketed with double extruded polyurethane jacket, each layer havinga thickness of 2.3 mm. The signal cable in the example further includeda central Kevlar strength member having a 1600 kg break strength.

Signal cable 30 can be an analog cable with each sensor 22 hard-wireddirectly to the remote location (as for example the surface).Alternately, the sensors 22 can be locally digitized and the digitaldata or signal can be multiplexed and sent to the remote location onmultiplexed signal conductors 36. The benefit of using multiplexedsignal conductors is that a lesser number of signal conductors isrequired. For example, in the example described herein wherein 240sensors were employed, 256 twisted pairs were used. However, when thesensors are provided with digitizers to digitize the signal, and 4signal channels are used, then a 64 twisted pair signal conductorarrangement can be employed. Multiplexing can be performed with opticalfiber conductors as well.

Fluid Conduit

The fluid conduit 40 of FIG. 3 is used to communicate a fluid to thereceiver deployment section, shown here as expansible section 50. Thefluid can be used to actuate the receiver deployment section. Forexample, the fluid in the conduit 40 can expand the expansible section50 causing the receiver 20 to be pressed up against the inner wall 3 ofthe borehole casing 5. This is shown graphically in FIG. 6 wherereceiver 20 has been pushed up against the inner side wall 3 due toexpansion of the resilient sleeve 52 which comprises a part ofexpansible section 50 and fluid conduit 40. Other embodiments ofreceiver deployment sections, and their techniques for being actuated byfluid within the fluid conduit 40, will be discussed further below.

In one embodiment, the fluid conduit 40 comprises a continuous piece ofcoil tubing having resilient expansible sleeves such as rubber bladdersplaced over the outside of the tubing at expansible section locations50. In those positions where the rubber bladder is placed over the coiltubing, the tubing is provided with holes to allow fluid within thefluid conduit to be forced outside of the fluid conduit, thus causingthe rubber bladder 52 to expand and push the receiver 20 into the casing5. In this embodiment, the rubber bladder 52 is secured to the coiledtubing by metal straps 154 of FIG. 4. Fluid conduit 40 can be a lengthof standard tubing or a length of coiled tubing. An embodiment whereinproduction tubing is used is discussed further below.

Coil tubing has the benefit of being capable of deployment into the wellfrom an industry standard coiled tubing rig, as indicated in FIG. 1.Such rigs allow the tubing to be wrapped on a spool rather than piecedtogether by individual straight pipe lengths. This allows a simplerdeployment of the apparatus in the field. Preferably, the coiled tubingis between about 2.3 cm and 7.9 cm (0.9 in. and 3.1 in.) in diameter.The only practical limit on the length of coiled tubing which can beemployed is the weight which must be supported by the coiled tubing whenit is deployed within a borehole. Coiled tubing lengths of 9000 m andgreater can be employed in the apparatus disclosed herein.

In a first embodiment of the fluid conduit 40 described above, thereceiver deployment section comprises a resilient sleeve 52 disposedabout the outside diameter of a continuous piece of coiled tubing asshown in FIG. 3. In this embodiment, non-continuous segments of coiledtubing are used between expansible sections 50. Expansible sections arepreferably provided with a resilient sleeve 52 having an uninflatedoutside diameter approximately equal to the outside diameter of the coiltube 42. In this way, a constant diameter for the fluid conduit 40 canbe maintained, allowing ease of spooling of the fluid conduit, it beingappreciated that when a resilient sleeve 52 having an outside diametergreater than the outside diameter of the coiled tube 42 is used, thefluid conduit will not be spooled in a smooth continuous manner.

Most preferably, the fluid conduit 40 further comprises an expansiblesection connector 60 which advantageously includes an expansible sectiontensile member 54 as shown in FIG. 4.

Positioning Device

A positioning device 70 shown in FIG. 3 which can be used in theembodiment described herein is shown in further detail in FIG. 9. FIG. 9shows a plan view of the positioning device 70 of FIG. 3. Thepositioning device 70 comprises a first half 144 and a second half 146which are coupled together by fasteners 148 and 150, which can comprisethreaded couplers. When coupled together, the first half 144 and thesecond half 146 define a first opening 152 which can receive fluidconduit 40 of FIG. 6, and a second opening 153 which can receive thesignal cable 30. In this manner, the fluid conduit 40 can be held inrelative position to signal cable 30 and hence receiver 20. This allowsthe receiver 20 to be accurately positioned with respect to the receiverdeployment section, here, expansible section 50.

In addition to positioning the receiver in the wellbore, the positioningdevice is also useful in dampening noise in the wellbore (“tube waves”),which are conducted by casing 5 of FIG. 1.

Expansible Section

As described above, in one embodiment the receiver deployment sectioncomprises an expansible section. Turning to FIG. 4, a detail of theupper end 122 of the expansible section 50 of the fluid conduit 40 shownin FIG. 3 is provided in detail. The expansible section 50 includes anexpandable sleeve 52 which is preferably a resilient sleeve. The sleevecan be fabricated from any material having a tendency to expand whensubjected to a differential pressure and preferably returned to itsoriginal size and shape once the applied pressure has been removed. Theresilient sleeve 52 can also be described as a rubber bladder. Apreferable material of construction is a nitrile elastomer. Morepreferably, the resilient sleeve 52 is fabricated from nitrile having ahardness of duro 60. An alternate material of construction for theresilient sleeve 52 is vinylidene flouride hexafluorpropylenetetrafluorethylene, available from E.I. du Pont de Nemours and Companyas “Viton”, having a hardness of duro 60.

The resilient sleeve 52 is coupled to the main tubing section 42 of thefluid conduit 40 by the expansible section connector 60. The expansiblesection connector 60 includes tubing end fitting 62 and expansiblesection connector end fitting 64. Expansible section connector 60further preferably and advantageously includes expansible sectiontensile member 54. Tubing end fitting 62 securedly engages the primarytubing 42. One method for such secure engagement is to swage the end oftubing 42 over the tubing end fitting 62. Another method to secure thetube 42 to the end fitting 62 is by welding. O-rings 66 and 68 arepreferably provided to provide a fluid-tight seal between the coiledtubing 42 and the tubing end fitting 62.

The expansible section tensile member 54 is securedly held in placeagainst the expansible section end fitting 64 by an appropriate methodas a swage fitting. O-rings 63 and 65 are employed to provide afluid-tight seal between expandable section tensile member 54 andexpandable section connector end fitting 64.

Tubing end fitting 62 is securedly engaged by expansible sectionconnector end fitting 64 by a method such as threads 69. Expandablesleeve 52 is preferably disposed about the outer diameter of expandablesection tensile member 54 and the exposed portion of expandable sectionconnector end fitting 64. The expandable sleeve 52 is securedly held insuch position by a metal strap 154, which can be fabricated fromstainless steel. In this manner, the fluid conduit 40 provides acontinuous strength member to support the apparatus when it is deployedfor example within a wellbore. As seen in FIG. 4, this also provides aconstant outside diameter for the fluid conduit 40.

In operation, fluid within fluid conduit 40 passes into the expansiblesection connector 60 by way of fluid passage 101 which is disposed inthe coiled tubing end fitting 62. Expandable section connector endfitting 64 is likewise provided with a fluid passage 124 allowing fluidto pass into the expandable section tensile member 54. The expandablesection tensile member 54 can be a piece or regular production tubing ora coiled tubing section. In one example, tubing section 42 is a 3.8 cm(1.5 in. nominal) diameter coiled tubing, and section tensile member 54is a 2.5 cm (1 in. nominal) expendable diameter coiled tubing section.

Preferably, the hollow tubing used for expandable section tensile member54 is provided with holes 56 allowing fluid to pass from within thefluid conduit into the space 110 between the outside diameter of theexpandable section tensile member 54 and the resilient sleeve 52. Whenthe fluid pressure within the fluid conduit is increased beyond thepressure at the outside diameter of the expandable sleeve 52, theexpandable sleeve is caused to expand in an outward manner, thus pushingagainst the receiver 20 of FIG. 3 and causing the receiver 20 to moveagainst the inner wall 3 of the casing 5.

Turning to FIG. 5, a side elevation view of the expandable sectionconnector 60 of FIG. 4 is shown. Upper end 122 and lower end 124 areshown with respect to similar upper and lower ends of FIG. 3. Theexpandable section connector 60 has a first expandable section connectorend fitting 64 and a second expandable section connector end fitting 61.Swaged about, or welded to, each of the expandable section connector endfittings is expandable section tensile member 54, which here comprises a2.5 cm diameter (1 in. nominal) hollow coiled tubing section 54.Advantageously, the threads 69 in the first expandable section connectorend fitting 64 are provided in a first direction, while the threads 106in the second expandable section connector end fitting 61 are providedin a second direction. For example, thread 69 can be right hand threadswhile threads 106 are left hand threads. In this example, the expandablesection connector 60 can be rotated in a single direction to engagetubing end fittings at each end of the expandable section connector 60.When the expandable section connector 60 is rotated in the oppositedirection, the tubing end fittings at each end of the expandable sectionconnector 60 will be disengaged from the connector. This has thebeneficial effect of allowing expandable sections 50 to be removed fromthe fluid conduit 40 without the need to rotate one end or the other ofthe fluid conduit 40 with respect to the expandable section 50. Thisbeneficial feature can be utilized for example to replace expandablesleeves 52 which may become damaged or worn in use.

Outer Sleeve

In yet an alternate embodiment, the signal cable 30, receivers 20, andthe fluid conduit 40, can be received within a secondary tubing 130.This is shown in side elevation view in FIG. 7 and in a plan sectionalview in FIG. 8. When the receiver deployment sections are actuated, (forexample, when expansible sections 50 within the fluid conduit 40expand), the receivers 20 will be pushed out of the secondary tubing 130into contact with the inner wall 3 of the casing 5. In this embodiment,the secondary tubing 130 essentially acts as a protective outer sleevein which the apparatus 10 is protectively contained until such time asthe apparatus is to be activated within the borehole. Once the pressurewithin the expansible section 50 is reduced, the receivers 20 and signalcable 30, retract back into the secondary coiled tubing 130.

Another embodiment of an apparatus in accordance with the presentinvention is shown in FIGS. 11-13. FIG. 11 depicts a receiver array 200which is similar to the receiver array 10 depicted in FIGS. 7 and 8. Themain similarity between the array shown in FIG. 8 and that shown in FIG.12 is the housing 130 and 230 (respectively) which surrounds thegeophone pod 20. The primary difference between the array shown in FIGS.7 and 8 and that shown in FIGS. 11 and 12 is the array in FIG. 7 uses anoff-center coiled tubing section 112 to conduct the fluid in the fluidconduit 40, while the array in FIG. 11 uses production tubing sections240 which are centered within the wellbore to conduct the fluid in thefluid conduit 40.

In the receiver array 200 shown in FIG. 11, the production tubingsections 240 can be coupled to the expansible section (not shown in FIG.11) using standard tubing collars 210. These standard tube collars havereverse threaded ends, allowing the coupling to be turned to disconnectthe production tubing section 240, without necessitating turning thetube section 240 or the geophone pod housing 230, as was describedabove.

The tube collars 210 are connected to pod housing conduit extensions220, which are in turn welded to the pod housing end caps 270. Thesignal cable 114 is secured to the pod housing end caps 270 to relievetension in the cable and impart the force to the end caps 270, andconsequently to the production tubing 240. Fluid passing through podhousing conduit extensions 220 is routed to the inner fluid conduit 254(shown in FIG. 12). Since the pod housing conduit extension 220 isessentially centered with respect to the wellbore, whereas the innerfluid conduit is located proximate to one side of the wellbore, the twoare connected by a piece of fluid conduit (not shown) having an offsetor a slight bend.

Turning now to FIG. 12, the receiver array 200 comprises an expansiblesection within the fluid conduit 40 of FIG. 11. The expansible sectioncomprises an inner conduit 254 and an expansible sleeve 52. The portionof the inner fluid conduit 254 which is covered by the expansible sleeve52 is perforated, allowing fluid to expand the expansible sleeve 52 inthe manner described above. However, unlike the embodiment describedabove, in the preferred embodiment the inner conduit 254 does notfunction as a primary tensile strength member. Rather, the receiverarray 200 employs tensile members 212 which are connected to the upperand lower end caps 270, thus communicating the weight of the geophonepods 20 and the signal cable 114 to the production tubing sections 240.One method of connecting the tensile members 212 to the end caps 270 isby welding.

In one embodiment the outside diameter of the geophone pod housing 230is sized to be approximately 0.5 inches (12 mm) less than the insidediameter of the wellbore casing 5. This has the effect of reducingpressure waves which can occur in the wellbore during use of thereceiver array. Such pressure waves, or “tube waves”, are recognized asa primary source of signal noise during down-hole seismic surveys, andtherefore reducing the magnitude of such tube waves has a beneficialeffect on the results of a survey taken using the downhole receiverarray 200.

In operation, as fluid is pumped through the fluid conduit at a pressurehigher than the pressure in the wellbore, the expansible sleeve 52expands, pushing against the inner wall of the pod housing 230 and thepod shoe 256. The pod shoe 256 pushes the geophone pod against the innerwall of the well casing 5 to couple the geophone pod to the well casing.After the desired data has been recorded, the fluid pressure within thefluid conduit is relieved, allowing the expansible sleeve to contractand the geophone pod to retract back into the pod housing 230.

FIG. 13 shows an alternate embodiment of the receiver array shown inFIG. 12. The receiver array 300 of FIG. 13 comprises four additionalsignal cables 314 in addition to the receiver cable 114, providing fivesignal cables in all. These signal cables can be connected in signalcommunication with geophone pods which are intended to be positioneddeeper within the wellbore than is the receiver 20 shown in FIG. 13. Forexample, in a receiver array having 100 geophone pods, the first cablecan be connect to the first twenty geophone pods, the second cable tothe second twenty geophone pods, and so on to the fifth cable. Thisallows data to be transmitted at a faster rate than using a singlecable, and allows for improved signal quality over multiplexing data ona single cable.

FIGS. 14 through 16 depict alternate apparatus for the receiverdeployment section which deploys the geophone pods from a retractedposition to a position which brings them into contact with the boreholewall. The embodiments of the receiver deployment section can replace theexpansible section embodiment described above. Each of the apparatusdepicted in FIGS. 14-16 are actuated by pressure within the tubing whichis used to support the geophone pods within the wellbore. I will nowdiscuss each of these three apparatus in detail.

Turning now to FIG. 14, a side sectional view of a segment of a singlereceiver deployment section 400 in accordance with the present inventionis depicted in a side elevation sectional view. The receiver deploymentsection 400 is part of a receiver array which includes a fluid conduit40, which is configured in the manner described above with respect toFIG. 7. In this configuration, the fluid tubing acts to support theweight of the array. The fluid conduit 40 includes relatively straightsections of tubing 410, which can be coiled tubing or tubing sections,as well as an offset tubing section 440 which is disposed between two ofthe straight tubing sections 410. The offset tubing section 440 can beconnected to the straight tubing sections 410 by threaded joints 442 orthe like. The offset tubing section is provided with offset bends ateach end such that the centerline of the offset section 440 is offsetfrom the centerlines of the straight tubing sections 410. This allowsone side of the offset tubing section 440 to be located proximate thewall 3 of a wellbore 5 in which the receiver array 400 can be deployed.The other side of the offset tubing section 440, that is, the side whichis opposite of the side near the wall 3 of the wellbore, provides aspace within the wellbore to receive a geophone pod 20.

Attached to the offset tubing section 440 is a geophone pod housingmember 444. As depicted, the geophone pod 20 is in a deployed positionin which the pod is in contact with the wall 3 of the wellbore 5. In anon-deployed position the geophone pod 20 is retracted to the left,towards the offset tubing section 440. In the retracted position thegeophone pod housing 444 provides mechanical protection for the geophonepod 20.

The geophone pod is connected to a signal cable 114, in a manner similarto that described above with respect to FIG. 7. The signal cable isfurther supported by the geophone pod housing 444 by cable supports 448which allow the cable to move with respect to the housing 444.Sufficient slack is provided in the signal cable 114 to allow thegeophone pod, to which the cable is attached, to move freely from thenon-deployed position (not shown) to the deployed position (shown).

In the embodiment depicted in FIG. 14 the receiver deployment sectioncomprises a spring 452, which is shown here as a single-element leafspring. The spring is connected to the geophone pod 20, and is disposedbetween the geophone pod 20 and the offset tube section 440 of theconduit. The spring is configured to bias the receiver or geophone pod20 away from a first position proximate the offset tube section 440 andtowards a second position proximate the inner wall 3 of the borehole 5,as depicted in the drawing. Spring end anchors 454 hold the ends of thespring 452 against the offset tube section 440, but are configured toallow the ends of the spring to slide freely through the anchors. Thisallows the spring 452 to be compressed (i.e., the geophone pod 20 to beheld away from the wall 3 of the borehole 5) without causing buckling ofthe spring element.

When the geophone pod 20 is in the first or non-deployed position (notshown) and the spring 452 is compressed, the pod 20 is held in theretracted position by the spring release mechanism 460 and pod catch464. The spring release mechanism comprises a mounting frame 465 whichis attached to the offset tubing section 440. The spring releasemechanism further includes a releasable latch 462 which is pivotallymounted to the mounting frame 465 at pivot mounting 468. The springrelease mechanism 460 (or “latch release device”) is actuated by apiston 466 which is disposed within an opening in the offset tubingsection 440. A first end of the piston 466 is in contact with a releaselever 470, which is part of the latch 462. A second end of the piston466 is disposed within the interior of the offset tubing section 440.The spring release mechanism can also include a seal 472 to preventfluids from escaping around the piston 466.

When the geophone pod 20 is in the non-deployed position the latch 462is rotated slightly clockwise such that it engages the pod catch 464 andholds the geophone pod 20 in the first or retracted position against theforce of the spring 452. When the geophone pod is to be deployed thepressure of the fluid in the fluid conduit 40 is increased to the pointwhere the differential pressure between the interior and exterior of thefluid conduit provides a sufficient force on the piston 466 to cause thepiston to be pushed against the release lever 470. The release leverthen causes the catch 462 to rotate in the direction indicated by arrow“B”, thus disengaging the catch 462 from the pod catch 464. The biasingforce of the spring 452 is then free to push the geophone pod 20 awayfrom the offset tube section 440 and into a second position in contactwith the wall 3 of the borehole 5.

Although a specific implementation of the spring 452 and spring releasemechanism 460 are depicted in FIG. 14 it is understood that any type ofspring and release mechanism which accomplish the same function of usingpressure in the tubing 40 to deploy the geophone pod 20 can be employed.For example, the geophone pod can be held in a retracted positionagainst the biasing force of the spring by a catch with is configured tobe electrically released, such as by a solenoid. The solenoid can beactuated by a pressure switch which is located within the offset tubingsection 440 and is connected electrically to the solenoid. Electricpower for the solenoid and the pressure switch can be provided for bythe conduit 114. The pressure switch generates an actuation signal at apredetermined pressure within the fluid conduit, and transmits thesignal to the spring release device, which then releases the spring,allowing the receiver to move away from the offset tubing section. Thisconfiguration eliminates any fluid sealing problems which may beassociated with the moving piston 466 penetrating the offset tubingsection.

Turning to FIG. 15, a third embodiment of a receiver deployment section500 in accordance with the present invention is shown. The view depictedin FIG. 15 is as side elevation sectional view, and is essentially thesame view as depicted in FIG. 14, except that the details of thereceiver deployment section 500 of FIG. 15 are different than thedetails of the receiver deployment section 400 of FIG. 14. The receiverarray is supported by tubing 40, which incorporates an offset tubingsection 440. A receiver or geophone pod 20 is positioned adjacent theoffset tubing section 440, and is connected to the receiver array bysignal cable 114.

Attached to the offset tubing section 440 is a geophone pod housingmember 540. As depicted, the geophone pod 20 is in a second or deployedposition in which the pod is in contact with the wall 3 of the wellbore5. In a first or non-deployed position the geophone pod 20 is retractedto the left, towards the offset tubing section 440. In the retractedposition the geophone pod housing (“receiver housing”) 540 providesmechanical protection for the geophone pod 20. The signal cable 114 isfurther supported by the geophone pod housing 540 by cable supports 548which allow the cable to move with respect to the housing 540.Sufficient slack is provided in the signal cable 114 to allow thegeophone pod, to which the cable is attached, to move freely from thenon-deployed position (not shown) to the deployed position (shown).

The receiver deployment section further includes a first piston 554 anda second piston 556, which each have a first end in contact with thegeophone pod 20. The main body of each piston is disposed through arespective first and second opening in the offset tubing section 440 ofthe fluid conduit 40, as well as through the geophone pod housing member540. A second end of each piston 554 and 556, which is located inside(i.e., within the interior) of the offset tubing section, has respectiveflanges 558 and 560 which prevent the pistons from passing beyond theoffset tubing section 440. The pistons 554 and 556 are sealed within theopenings in the pod housing member 540 by seals 552. Seals 552 allow thepistons to move within the openings in the offset tubing section 440 andthe pod housing 540, but restrict fluid flow between the interior of theoffset tubing section and the wellbore.

When the receiver array is deployed in the wellbore, the geophone pod 20is in a retracted position (not shown) wherein the pod 20 is positionedto the left of the position depicted in FIG. 15. In this retractedposition, the pistons 554 and 556 are also positioned to the left of theposition shown. When the geophone pod 20 is to be deployed and coupledto the wall 3 of the wellbore 5, fluid pressure within the conduit 40,and hence the offset tubing section 440, is increased until thedifferential pressure between the interior and the exterior of the fluidconduit generates sufficient force on the flanges 558 and 560 of thepistons 554 and 556 to cause them to move to the right (as depicted).When this condition is met the pistons 554 and 556 push the geophone pod20 to the right (i.e., to the position depicted in FIG. 15) until thegeophone pod either couples with the wall 3 of the wellbore, or themaximum allowable travel of the pistons is achieved.

The pistons 554 and 556 can be connected to the geophone pod 20 (asopposed to merely resting in contact with the pod) such that thegeophone pod can be retracted by decreasing the pressure in the conduit40 until pressure within the wellbore 5 overcomes any frictionalresistance between the pistons and the seals 552, and the pistons arepushed back into the offset tubing section 440.

Turning now to FIG. 16, a fourth embodiment of a receiver deploymentsection 600 in accordance with the present invention is shown. The viewdepicted in FIG. 16 is as side elevation sectional view, and isessentially the same view as depicted in FIGS. 14 and 15, except thatthe details of the receiver deployment section 600 of FIG. 16 aredifferent than the details of the receiver deployment sections 400 and500 of respective FIGS. 14 and 15. The receiver array is supported bytubing 40, which incorporates an offset tubing section 440. A geophonepod 20 is positioned adjacent the offset tubing section 440, and isconnected to the receiver array by signal cable 114.

Attached to the offset tubing section 440 is a geophone pod housingmember 660 (a “receiver housing”). As depicted, the geophone pod 20 isin a second or deployed position in which the pod is in contact with thewall 3 of the wellbore 5. In a first or non-deployed position thegeophone pod 20 is retracted to the left, towards the offset tubingsection 440. In the retracted position the geophone pod housing 660provides mechanical protection for the geophone pod 20. The signal cable114 is further supported by the geophone pod housing 660 by cablesupports 648 which allow the cable 114 to move with respect to thehousing 660. Sufficient slack is provided in the signal cable 114 toallow the geophone pod, to which the cable is attached, to move freelyfrom the non-deployed position (not shown) to the deployed position(shown).

The receiver deployment section 600 further includes first and secondclamping arms 670 and 672, which each have a first end pivotallyattached to the pod housing 660 at first pivot connections 674. A secondend of each clamping arms is pivotally attached at second pivotconnections 678 to first and second connector pads 673, which are inturn connected to the geophone pod 20. First and second pistons, 654 and656, are deployed with respect to the offset tubing section 440 and thegeophone pod housing 660 in a manner similar to the pistons 554 and 556of FIG. 15. That is, pistons 654 and 656 are disposed through first andsecond openings in the offset tubing section and the geophone podhousing 660. The pistons are defined by first and second ends. Thesecond ends of the pistons are located within the offset tubing section440. These second ends of the pistons 654 and 656 are provided withrespective flanges 658 and 662 which arrest right-ward movement (asviewed in FIG. 16) of the pistons with respect to the offset tubingsection Further, seals 652 aid in resisting fluid movement around thepistons between the wellbore 5 and the inside of the conduit 40.

However, unlike the pistons 554 and 556 depicted in FIG. 15, which areconnected directly to the geophone pod 20, the pistons 654 and 656 ofFIG. 16 have first ends which are pivotally attached to respectiveclamping arms 670 and 672 at respective third pivot connections 676 and678. In this way, as the pistons are moved rightward to the “deployed”position depicted in FIG. 16, the clamping arms 670 and 672 pivot aboutfirst pivot connections 674, and push the geophone pod 20 into contactwith the wall 3 of the wellbore 5 (or at least until the movement of theclamping arms is restricted by the flanges 658 and 662 connecting withthe inner wall of the offset tubing section 440).

As with the receiver deployment section 500 of FIG. 15, the receiverdeployment section 600 of FIG. 16 is actuated by an increase of pressurewithin the conduit 40 (and the offset tubing section 440). As thedifferential pressure between the interior and exterior of the fluidconduit 40 (and offset tubing section 440) increases, the force on theflanges 658 and 662 increases until the pistons 654 and 656 push on theclamping arms 670 and 672 cause the geophone pod to move to the deployedposition (depicted in FIG. 16). By reducing the pressure within theoffset tubing section, the external forces acting on the geophone pod 20push the pistons 654 and 656 back to the left (as viewed in FIG. 16),and the pod 20 is retracted.

Operation

Returning to FIG. 1, as described previously, the apparatus ispreferably actuated by inflating the expansible sections 50 to cause thereceivers 20 to be pressed against the casing 5. This can beaccomplished by increasing the pressure within the fluid conduit 40 to apressure beyond that inside the wellbore 4, thus causing the expansiblesections to expand. In a first embodiment, a static fluid can bemaintained within the fluid conduit 40 having a pressure maintained by apressure source 7 of FIG. 1 which can comprise a pump or a compressor.

More preferably, a fluid is circulated within the fluid conduit 40. Inthis embodiment, the lower-most end 126 of the fluid conduit 40 isprovided with a flow restrictor 15. The flow restrictor can comprise avalve configured to close when the pressure within the fluid conduitrises to a certain preselected pressure. More preferably, the flowrestrictor 15 comprises a fused valve configured to close at apreselected differential pressure between the pressure within the fluidconduit 40 and the wellbore 4. The apparatus 100 can be actuated byincreasing the pressure of fluid within the fluid conduit 40 by fluidpressure source 7 for example. The fused valve 15 advantageouslyprovides a fast acting response to pressure increases within the fluidconduit 40. When the expansible sections 50 have been actuated, thereceivers are caused to move towards the casing 5 as shown in FIG. 6.Once the pressure within the fluid conduit 40 drops below a preselectedpressure differential with the pressure in the wellbore 4, the fusedvalve 15 opens allowing fluid to be circulated through the fluid conduit40.

When the apparatus is deployed in a reservoir in which the borehole isfilled with a liquid fluid, it is preferable to use the same liquidfluid within the fluid conduit as the working fluid in the wellbore toexpand the expansible sections. This provides a pressure balanced systemprior to closing the valve 15, which is beneficial to the properfunctioning of the packers 52. In other applications, the apparatus canbe deployed within a wellbore in which a gaseous fluid is contained, asfor example in a natural gas field. In this application, it ispreferably to use a gaseous fluid within the fluid conduit as theworking fluid to expand the expansible sections.

Turning to FIG. 17, a method of deploying a receiver array of thepresent invention on the bottom of a lake or an ocean floor is depicted.The view in FIG. 17 is a side elevation view of a body of water 701,such as an ocean, having an upper surface 703 and defined by anessentially horizontal bottom surface 705. In this application thereceiver array 710 can be deployed from a water craft 707 by adeployment apparatus 708. Unlike the applications discussed previouslywherein a receiver array is disposed within a wellbore, in theapplication depicted in FIG. 17 the portion of the receiver arraycontaining the receivers or geophones rests directly on the bottomsurface 705. This application is an alternative to using towed arrays ofgeophones (i.e., an array of geophones towed in the water behind aboat). The advantage of the deployment method depicted in FIG. 17 isthat the geophones are in direct contact with the bottom surface 705,and thus a better signal can be received, since the signal will not beattenuated by the body of water, as is the case when using a towedarray.

As depicted, the receiver array 710 of FIG. 17 comprises a plurality ofgeophone pods 20. The geophone pods 20 can be supported in the array inany of the manners disclosed herein above. Further, the receiverdeployment section used to move the geophone pods into a position tocontact the bottom surface can be any of the receiver deploymentsections disclosed herein. In the example depicted in FIG. 17, thereceiver array has a cross section similar to the receiver arraydepicted in FIG. 12. That is, the receiver array uses an expansiblesection as the receiver deployment section. The array 710 furtherincludes locators 712, which facilitate in properly orienting thegeophone pods 20 with respect to the bottom surface 705.

Turning now to FIG. 18, a side sectional view of the receiver array 710of FIG. 17 is depicted. In the view depicted in FIG. 18, the geophonepod has been deployed (as evidenced by the expanded expansible section52) and is in contact with the bottom surface 705. The locator 712 isconnected to the geophone pod housing 230 by brackets 716. The locatorcan comprise a central curved or circular section which will allow thereceiver array 710 to roll on the bottom surface 705. The locator canalso include “feet” 714, which arrest the geophone pod 20 in apredetermined position where the pod can contact the bottom surface 705when the pod is deployed from the pod housing 230. The receiver array710 can further include sensors (not shown) which are connected to thesignal cable and can signal when the receiver array is properly orientedwith respect to the bottom surface 705.

In compliance with the statute, the invention has been described inlanguage more or less specific as to structural and methodical features.

It is to be understood, however, that the invention is not limited tothe specific features shown and described, since the means hereindisclosed comprise preferred forms of putting the invention into effect.The invention is, therefore, claimed in any of its forms ormodifications within the proper scope of the appended claimsappropriately interpreted in accordance with the doctrine ofequivalents.

I claim:
 1. An apparatus for detecting geophysical energy, comprising: areceiver configured to receive geophysical energy characterized by aplurality of characteristics, and convert said geophysical energy into asignal representative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; a receiver deployment section configured to be actuated inresponse to an increase of fluid pressure within said conduit, and whenactuated, to cause the receiver to be moved from a first position to asecond position; a spring disposed between the conduit and the receiverand configured to bias the receiver away from the conduit to the secondposition; a releasable latch for temporarily securing the receiver inthe first position; and a latch release device configured to release thelatch in response to pressure within the conduit.
 2. The apparatus ofclaim 1, and wherein: the latch is pivotally mounted and is configuredto release the receiver when the latch is pivoted; and the latch releasedevice comprises a piston movably disposed through an opening in theconduit, the piston having a first end configured to push the latch andcause it to pivot when the piston is moved in the opening in theconduit, and wherein the piston moves within the opening in the conduitas a result of a differential pressure between the interior and theexterior of the conduit.
 3. The apparatus of claim 1, and wherein: thelatch is electrically actuated in response to an actuation signal; andthe latch release device comprises a pressure switch within the interiorof the conduit, the pressure switch configured to generate the actuationsignal in response to a predetermined pressure within the interior ofthe conduit.
 4. An apparatus for detecting geophysical energy,comprising: a receiver configured to receive geophysical energycharacterized by a plurality of characteristics, and convert saidgeophysical energy into a signal representative of at least onecharacteristic of said geophysical energy; a signal transport deviceconfigured to accept said signal and relay said signal to a remotelocation; a fluid conduit configured to contain a pressurized fluid, thefluid conduit defining an interior and an exterior; and a receiverdeployment section configured to be actuated in response to an increaseof fluid pressure within said conduit, and when actuated, to cause thereceiver to be moved from a first position to a second position, andwherein the receiver deployment section comprises a first piston movablydisposed through a first opening in the conduit, the first piston havinga first piston first end configured to contact the receiver and to movethe receiver from the first position to the second position when thefirst piston is moved in the first opening in the conduit, and whereinthe first piston moves within the first opening in the conduit as aresult of a differential pressure between the interior and the exteriorof the conduit.
 5. The apparatus of claim 4, and wherein the receiverdeployment section further comprises a second piston movably disposedthrough a second opening in the conduit, the second piston having asecond piston first end configured to contact the receiver and to movethe receiver from the first position to the second position when thesecond piston is moved in the second opening in the conduit, and whereinthe first piston moves within the second opening in the conduit as aresult of a differential pressure between the interior and the exteriorof the conduit.
 6. The apparatus of claim 4, and wherein the apparatusfurther comprises a receiver housing attached to the fluid conduit andconfigured to receive at least part of the receiver when the receiver isin the first position.
 7. An apparatus for detecting geophysical energy,comprising: a receiver configured to receive geophysical energycharacterized by a plurality of characteristics, and convert saidgeophysical energy into a signal representative of at least onecharacteristic of said geophysical energy; a signal transport deviceconfigured to accept said signal and relay said signal to a remotelocation; a fluid conduit configured to contain a pressurized fluid, thefluid conduit defining an interior and an exterior; and a receiverdeployment section configured to be actuated in response to an increaseof fluid pressure within said conduit, and when actuated, to cause thereceiver to be moved from a first position to a second position, andwherein the receiver deployment section comprises: a receiver housingattached to the fluid conduit and configured to receive at least part ofthe receiver when the receiver is in the first position; a firstconnector pad connected to the receiver; a first clamping arm defined bya first end and second end, the first clamping arm first end beingpivotally attached to the receiver housing, and the first clamping armsecond end being pivotally attached to the first connector pad; and afirst piston movably disposed through a first opening in the conduit,the first piston having a first end configured to contact the firstclamping arm and to move the first clamping arm when the first piston ismoved in the first opening in the conduit, and wherein the first pistonmoves within the first opening in the conduit as a result of adifferential pressure between the interior and the exterior of theconduit.
 8. The apparatus of claim 7, and wherein the receiverdeployment section further comprises: a second connector pad connectedto the receiver; a second clamping arm defined by a first end and secondend, the second clamping arm first end being pivotally attached to thereceiver housing, and the second clamping arm second end being pivotallyattached to the second connector pad; and a second piston movablydisposed through a second opening in the conduit, the second pistonhaving a first end configured to contact the second clamping arm and tomove the second clamping arm when the first piston is moved in the firstopening in the conduit, and wherein the second piston moves within thesecond opening in the conduit as a result of a differential pressurebetween the interior and the exterior of the conduit.
 9. An apparatusfor detecting geophysical energy, comprising: a receiver configured toreceive geophysical energy characterized by a plurality ofcharacteristics, and convert said geophysical energy into a signalrepresentative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; a receiver deployment section configured to be actuated inresponse to an increase of fluid pressure within said conduit, and whenactuated, to cause the receiver to be moved from a first position to asecond position; and a locator attached to the fluid conduit, thelocator being configured to orient the receiver into a predeterminedposition with respect to an essentially horizontal surface upon whichthe apparatus may rest.
 10. The apparatus of claim 9, and wherein thelocator comprises a curved section to allow the apparatus to roll on thesurface upon which the apparatus may rest, and a foot to arrest theapparatus when the receiver is oriented in the predetermined position.11. An apparatus for detecting geophysical energy, comprising: areceiver configured to receive geophysical energy characterized by aplurality of characteristics, and convert said geophysical energy into asignal representative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; a receiver deployment section configured to be actuated inresponse to an increase of fluid pressure within said conduit, and whenactuated, to cause the receiver to be moved from a first position to asecond position; a receiver housing attached to the fluid conduit andconfigured to receive at least part of the receiver when the receiver isin the first position; and a locator attached to the receiver housing,the locator being configured to orient the receiver into a predeterminedposition with respect to an essentially horizontal surface upon whichthe apparatus may rest.
 12. The apparatus of claim 11, and wherein thelocator comprises a curved section to allow the apparatus to roll on thesurface upon which the apparatus may rest, and a foot to arrest theapparatus when the receiver is oriented in the predetermined position.13. An apparatus for detecting geophysical energy, comprising: areceiver configured to receive geophysical energy characterized by aplurality of characteristics, and convert said geophysical energy into asignal representative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; and a receiver deployment section configured to be actuatedin response to an increase of fluid pressure within said conduit, andwhen actuated, to cause the receiver to be moved from a first positionto a second position, and wherein at least a part of the fluid conduitcomprises an offset tubing section, and further wherein the receiverdeployment section is disposed between the offset tubing section and thereceiver.
 14. An apparatus for detecting geophysical energy, comprising:a receiver configured to receive geophysical energy characterized by aplurality of characteristics, and convert said geophysical energy into asignal representative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; and a receiver deployment section configured to be actuatedin response to an increase of fluid pressure within said conduit, andwhen actuated, to cause the receiver to be moved from a first positionto a second position, and wherein said signal transport device comprisesa signal cable comprising a signal conductor, said signal cable beingconnected to said receiver.
 15. An apparatus for detecting geophysicalenergy, comprising: a receiver configured to receive geophysical energycharacterized by a plurality of characteristics, and convert saidgeophysical energy into a signal representative of at least onecharacteristic of said geophysical energy; a signal transport deviceconfigured to accept said signal and relay said signal to a remotelocation; a fluid conduit configured to contain a pressurized fluid, thefluid conduit defining an interior and an exterior; and a receiverdeployment section configured to be actuated in response to an increaseof fluid pressure within said conduit, and when actuated, to cause thereceiver to be moved from a first position to a second position, andwherein said receiver comprises a geophone configured to record at leastthree of said characteristics.
 16. An apparatus for detectinggeophysical energy, comprising: a receiver configured to receivegeophysical energy characterized by a plurality of characteristics, andconvert said geophysical energy into a signal representative of at leastone characteristic of said geophysical energy; a signal transport deviceconfigured to accept said signal and relay said signal to a remotelocation; a fluid conduit configured to contain a pressurized fluid, thefluid conduit defining an interior and an exterior; and a receiverdeployment section configured to be actuated in response to an increaseof fluid pressure within said conduit, and when actuated, to cause thereceiver to be moved from a first position to a second position, andwherein said fluid conduit comprises standard production tubing.
 17. Anapparatus for detecting geophysical energy, comprising: a receiverconfigured to receive geophysical energy characterized by a plurality ofcharacteristics, and convert said geophysical energy into a signalrepresentative of at least one characteristic of said geophysicalenergy; a signal transport device configured to accept said signal andrelay said signal to a remote location; a fluid conduit configured tocontain a pressurized fluid, the fluid conduit defining an interior andan exterior; a receiver deployment section configured to be actuated inresponse to an increase of fluid pressure within said conduit, and whenactuated, to cause the receiver to be moved from a first position to asecond position; and a plurality of receivers in spaced-apartrelationship, said fluid conduit further comprising a plurality ofreceiver deployment sections in spaced apart relationship, individualsaid receivers being located proximate individual said receiverdeployment sections.
 18. The apparatus of claim 17 wherein said signaltransport device comprises a signal cable comprising a signal conductor,said signal cable being connected to each said receiver.
 19. Theapparatus of claim 17 wherein said signal transport device comprises aplurality of signal cables, each said signal cable comprising a signalconductor, a first one of said signal cables being connected to a firstplurality of said receivers, and a second one of said signal cablesbeing connected to a second plurality of said receivers.
 20. Theapparatus of claim 17 wherein said fluid conduit further comprisesstandard production tubing sections, individual standard productiontubing sections being disposed between individual said receiverdeployment sections.
 21. A marine bottom surface acoustic receiverarray, comprising: a plurality of seismic energy receivers, individualsaid receivers configured to receive geophysical energy characterized bya plurality of characteristics and convert said geophysical energy intosignals representative of at least one characteristic of saidgeophysical energy; a signal cable configured to accept said signals andrelay said signals to a remote location; a fluid conduit configured tocontain a pressurized fluid, said conduit comprising receiver deploymentsections located proximate to individual said receivers, said individualreceiver deployment sections configured to be actuated in response to anincrease of fluid pressure within said conduit, and when actuated, tocause the receiver to be moved from a first position to a secondposition to contact the marine bottom surface; a fluid pressure sourceconfigured to increase pressure of fluid which can be contained withinsaid conduit; a plurality of receiver housings attached to the fluidconduit, each receiver housing configured to receive at least part ofone of the receivers when the receiver is in the first position; and aplurality of locators attached to dedicated ones of the receiverhousings, the locators being configured to orient the receivers into apredetermined position with respect to the marine bottom surface.